Identifier

Author

Degree

Master of Science in Petroleum Engineering (MSPE)

Department

Petroleum Engineering

Document Type

Thesis

Abstract

The use of foam for mobility control is a promising means to improve sweep efficiency in subsurface applications such as improved/enhanced oil recovery and aquifer remediation. Foam can be introduced into geological formations by injecting gas and surfactant solutions simultaneously or alternatively. Alternating gas and surfactant solutions, which is often referred to as surfactant-alternating-gas (SAG) process, is known to effectively create fine-textured strong foams due to fluctuation in capillary pressure. Recent studies show that foam rheology in porous media can be characterized by foam-catastrophe theory which exhibits three foam states (weak-foam, strong-foam, and intermediate states) and two strong-foam regimes (high-quality and low-quality regimes). Using both mechanistic foam simulation technique and fractional flow analysis which are consistent with foam catastrophe theory, this study aims to understand the fundamentals of dynamic foam displacement during gas injection in SAG processes. The results revealed some important findings: (1) The complicated mechanistic foam fractional flow curves (fw vs. Sw) with both positive and negative slopes require a novel approach to solve the problem analytically rather than the typical method of constructing a tangent line from the initial condition; (2) None of the conventional mechanistic foam simulation and fractional flow analysis can fully capture sharply-changing dynamic foam behavior at the leading edge of gas bank, which can be overcome by the pressure-modification algorithm suggested in this study; (3) Four foam model parameters („¤Po, n, Cg/Cc, and Cf) can be determined systematically by using an S-shaped foam catastrophe curve, a two flow regime map, and a coreflood experiment showing the onset of foam generation; and (4) At given input data set of foam simulation parameters, the inlet effect (i.e., a delay in strong-foam propagation near the core face) is scaled by the system length, and therefore the change in system length at fixed inlet-effect length requires the change in individual values Cg and Cc at the same Cg / Cc. This study improves our understanding of foam field applications, especially for gas injection during SAG processes by capturing realistic pressure responses. This study also suggests new fractional flow solutions which do not follow conventional fractional flow analysis.